Page 121 - Petroleum Production Engineering, A Computer-Assisted Approach

Guo, Boyun / Computer Assited Petroleum Production Engg 0750682701_chap09 Final Proof page 115 21.12.2006 2:16pm

WELL TUBING 9/115
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9.2 Consider a 2 ⁄ 8 -in. API, 6.40 lb/ft Grade J-55 non- Initial condition: Tubing and casing are full of 30
upset tubing anchored with a packer set at 8,000 ft. API oil (S.G. ¼ 0.88)
The crude oil production through the tubing from the Operation: Tubing is displaced with 12 ppg cement
bottom of the hole is 1,500 stb/day (no gas or water with an injection pressure 4,500 psi and
production). A completion fluid is in place in the casing pressure 1,200 psi. The average
annular space between the tubing and the casing temperature drop is 30 8F.
(9.6 lb/gal KCl water). Assuming surface temperature a. Calculate tubing movement if the tubing is not
is 80 8F and geothermal gradient of 0.01 8F/ft, deter- restrained by the packer, and discuss solutions to
mine the landing tension to avoid buckling. the possible operation problems.
9.3 The following data are given for a frac-packing job: b. Calculate the tubing force acting on a restraining
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Tubing: 2 ⁄ 8 in., 6.5 lb/ft (2.441 in. ID) packer.
Casing: 7 in., 32 lb/ft (6.094 in. ID)
Packer: Bore size D p ¼ 3:25 in., set at 8,000 ft